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WO2023126567A1 - Charge d'hydrocarbures de gamme naphta stabilisée renouvelable, procédé de craquage thermique et produits associés - Google Patents

Charge d'hydrocarbures de gamme naphta stabilisée renouvelable, procédé de craquage thermique et produits associés Download PDF

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Publication number
WO2023126567A1
WO2023126567A1 PCT/FI2022/050771 FI2022050771W WO2023126567A1 WO 2023126567 A1 WO2023126567 A1 WO 2023126567A1 FI 2022050771 W FI2022050771 W FI 2022050771W WO 2023126567 A1 WO2023126567 A1 WO 2023126567A1
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WO
WIPO (PCT)
Prior art keywords
less
renewable
range
hydrocarbon feed
content
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PCT/FI2022/050771
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English (en)
Inventor
John Jamieson
Andres MUNOZ GANDARILLAS
Antti Ojala
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Neste Oyj
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Neste Oyj
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Application filed by Neste Oyj filed Critical Neste Oyj
Priority to KR1020247020041A priority Critical patent/KR20240107331A/ko
Priority to CA3237286A priority patent/CA3237286A1/fr
Priority to JP2024539335A priority patent/JP2025501191A/ja
Priority to EP22813634.7A priority patent/EP4457312A1/fr
Priority to US18/724,301 priority patent/US20250066682A1/en
Priority to CN202280084059.6A priority patent/CN118369403A/zh
Publication of WO2023126567A1 publication Critical patent/WO2023126567A1/fr
Anticipated expiration legal-status Critical
Ceased legal-status Critical Current

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Classifications

    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G9/00—Thermal non-catalytic cracking, in the absence of hydrogen, of hydrocarbon oils
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G9/00—Thermal non-catalytic cracking, in the absence of hydrogen, of hydrocarbon oils
    • C10G9/34—Thermal non-catalytic cracking, in the absence of hydrogen, of hydrocarbon oils by direct contact with inert preheated fluids, e.g. with molten metals or salts
    • C10G9/36—Thermal non-catalytic cracking, in the absence of hydrogen, of hydrocarbon oils by direct contact with inert preheated fluids, e.g. with molten metals or salts with heated gases or vapours
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G69/00—Treatment of hydrocarbon oils by at least one hydrotreatment process and at least one other conversion process
    • C10G69/02—Treatment of hydrocarbon oils by at least one hydrotreatment process and at least one other conversion process plural serial stages only
    • C10G69/12—Treatment of hydrocarbon oils by at least one hydrotreatment process and at least one other conversion process plural serial stages only including at least one polymerisation or alkylation step
    • C10G69/126—Treatment of hydrocarbon oils by at least one hydrotreatment process and at least one other conversion process plural serial stages only including at least one polymerisation or alkylation step polymerisation, e.g. oligomerisation
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G35/00—Reforming naphtha
    • C10G35/02—Thermal reforming
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
    • C10G2300/10—Feedstock materials
    • C10G2300/1011—Biomass
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
    • C10G2300/10—Feedstock materials
    • C10G2300/1037—Hydrocarbon fractions
    • C10G2300/1044—Heavy gasoline or naphtha having a boiling range of about 100 - 180 °C
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
    • C10G2300/40—Characteristics of the process deviating from typical ways of processing
    • C10G2300/4006—Temperature
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
    • C10G2300/80—Additives
    • C10G2300/805—Water
    • C10G2300/807—Steam
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G2400/00—Products obtained by processes covered by groups C10G9/00 - C10G69/14
    • C10G2400/20—C2-C4 olefins
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G2400/00—Products obtained by processes covered by groups C10G9/00 - C10G69/14
    • C10G2400/30—Aromatics

Definitions

  • the present invention relates to a method comprising thermal cracking, a renewable stabilized naphtha-range hydrocarbon feed usable in such a method and products obtainable by use of such a method.
  • Thermal cracking such as steam cracking
  • steam cracking is a well-known and established route for upgrading conventional (mineral oil based) material.
  • thermal cracking of biogenic material has been investigated, while it was usually tried to achieve direct cracking of a biogenic feed (usually having high oxygen content) or to mimic conventional (fossil) feeds.
  • High value chemicals produced in the thermal cracking process are ethylene, propylene, butadiene, olefinic C4, benzene, xylene and toluene.
  • ethylene and propylene are the most sought after in industry.
  • C4 olefins are also valuable products but may require additional refining steps to extract chemical and polymer grades of each individual component.
  • Aromatics are of less importance as there are other routes to their manufacture such as reforming of fossil naphtha.
  • benzene may enrich in a pyrolysis gasoline fraction of the cracking effluent which is typically valorised in fuels. Since there are stringent limitations in the amount of benzene allowable in such fuel products (due to its carcinogenic effects) it may even become an unwanted by-product which requires removal.
  • the present invention was made in view of the above-mentioned problems and it is an object of the present invention to provide a renewable stabilized naphtha-range hydrocarbon feed, a thermal cracking method employing the renewable stabilized naphtha-range hydrocarbon feed and products emerging from the method as well as their use and further processing.
  • the present invention relates to one or more of the following items:
  • step (c) a step of subjecting the effluent of the thermal cracking furnace of step (b) to a separation treatment to provide at least a light olefin(s) fraction.
  • thermal cracking step (b) is conducted at a coil outlet temperature (COT) selected from the range from 780°C to 880°C, preferably from 800°C to 860°C, more preferably from 820°C to 850°C. 3.
  • COT coil outlet temperature
  • COP coil outlet pressure
  • thermo cracking step (b) is a steam cracking step.
  • thermo cracking step (b) is conducted in the presence of a thermal cracking diluent at a dilution within a range from 0.10 to 0.85, preferably from 0.25 to 0.60, such as 0.35 to 0.55.
  • step (c) further comprises adding the further effluent(s) and/or fraction(s) thereof to the effluent of the thermal cracking furnace of step (b) before and/or during the separation treatment.
  • step (b) is carried out in the presence of co-feed(s).
  • the content of the renewable stabilized naphtha-range hydrocarbon feed in the total cracker feed is in the range of from 10 wt.-% to 100 wt.-%, preferably 20 wt.-% to 100 wt.-%, 30 wt.-% to 100 wt.-%, 40 wt.-% to 100 wt.-%, 50 wt.-% to 100 wt.-%, 60 wt.-% to 100 wt.-%, 70 wt.-% to 100 wt.-%, 80 wt.-% to 100 wt.-%, or 90 wt.-% to 100 wt.-%, wherein the total cracker feed refers to the renewable stabilized naphtha-range hydrocarbon feed plus optional co- feed(s) and optional additive(s).
  • the total cracker feed has a sulphur content in the range from 20 to 300 ppm by weight, preferably 20 to 250 ppm by weight, more preferably 20 to 100 ppm by weight, and even more preferably 50 to 65 ppm by weight.
  • step (a) of providing the renewable stabilized naphtha-range hydrocarbon feed comprises a stage of subjecting an oxygenate bio-renewable feed to hydrotreatment comprising at least hydrodeoxygenation to provide at least a liquid hydrocarbon stream, and a stage of subjecting at least part of the liquid hydrocarbon stream to fractionation and recovering at least the renewable stabilized naphtha-range hydrocarbon feed.
  • the hydrotreatment comprises at least the hydrodeoxygenation to provide a hydrotreatment effluent
  • the hydrotreatment effluent is subjected to gas-liquid separation to provide a gaseous stream and a first liquid hydrocarbon stream
  • at least part of the first liquid hydrocarbon stream is subjected to a further hydrotreatment comprising at least hydroisomerisation, followed by optional further gas-liquid separation, to provide at least a second liquid hydrocarbon stream
  • subjecting at least part of the second liquid hydrocarbon stream as the liquid hydrocarbon stream to the fractionation and recovering of at least the renewable stabilized naphtha-range hydrocarbon feed
  • stage of subjecting at least part of the liquid hydrocarbon stream to fractionation and recovering at least the renewable stabilized naphtharange hydrocarbon feed further comprises recovering a heavy liquid hydrocarbon fraction.
  • the stage of subjecting at least part of the liquid hydrocarbon stream to fractionation and recovering at least the renewable stabilized naphtharange hydrocarbon feed further comprises recovering at least an aviation fuel range fraction and/or a diesel range fraction.
  • stage of subjecting at least part of the liquid hydrocarbon stream to fractionation and recovering at least the renewable stabilized naphtha-range hydrocarbon feed comprises at least subjecting at least part of the liquid hydrocarbon stream to fractionation to provide a naphtha range fraction, and subjecting the naphtha range fraction to stabilization, wherein the stabilisation comprises removing, preferably by means of a distillation technique, at least part of components boiling below 20°C, preferably at least part of components boiling below 25°C, at least part of components boiling below 30°C, at least part of components boiling below 40°C or at least part of components boiling below 50°C.
  • step (a) of providing a renewable stabilized naphtha-range hydrocarbon feed comprises: subjecting an oxygenate bio-renewable feed to hydrotreatment comprising at least hydrodeoxygenation to provide a hydrotreatment effluent, subjecting at least part of the hydrotreatment effluent to gas-liquid separation to provide a gaseous stream and a first liquid hydrocarbon stream, providing the first liquid hydrocarbon stream as a liquid hydrocarbon stream or subjecting at least part of the first liquid hydrocarbon stream to a further hydrotreatment comprising at least hydroisomerisation, followed by optional further gas-liquid separation, to provide at least a second liquid hydrocarbon stream as the liquid hydrocarbon stream, and feeding at least part of the liquid hydrocarbon stream to a first distillation column, preferably a first stabilisation column, to obtain a first overhead fraction and a stabilised heavy liquid hydrocarbon fraction, optionally using at least part of the stabilised heavy liquid hydrocarbon fraction in diesel fuel and/or recovering from at least part of the stabilised heavy
  • step (d) a step of (co)polymerizing at least one of the light olefin(s) separated in step (c) and/or at least one of the bio-monomer(s), optionally together with other (co)monomer(s) and/or after optional further purification, to produce a biopolymer composition.
  • biopolymer composition is further processed to produce a sanitary article, a construction material, a packaging material, a coating composition, a paint, a decorative material, such as a panel, an interior part of a vehicle, such as an interior part of a car, a rubber composition, a tire or tire component, a toner, a personal health care article, a part of a consumer good, a part or a housing of an electronic device, a film, a moulded product, a gasket, optionally together with other components.
  • a renewable stabilized naphtha-range hydrocarbon feed for thermal cracking 29.
  • renewable stabilized naphtha-range hydrocarbon feed according to item 29, wherein the renewable stabilized naphtha-range hydrocarbon feed has a content of naphthenes in the range of from 0.1 wt.-% to 10.0 wt.-% based on the total weight of the renewable stabilized naphtha-range hydrocarbon feed. 31.
  • renewable stabilized naphtha-range hydrocarbon feed according to any one of items 29 to 31, wherein the renewable stabilized naphtha-range hydrocarbon feed has a content of olefins of 0.50 wt.-% or less, preferably 0.40 wt.-% or less, 0.30 wt.-% or less, 0.25 wt.-% or less, 0.20 wt.-% or less, 0.15 wt.-% or less, 0.12 wt.-% or less, 0.10 wt.-% or less, 0.07 wt.-% or less, or 0.05 wt.-% or less.
  • renewable stabilized naphtha-range hydrocarbon feed according to any one of items 29 to 32, wherein the renewable stabilized naphtha-range hydrocarbon feed has a total content of olefins and naphthenes in the range from 0.1 wt.-% to 10.0 wt.-%.
  • renewable stabilized naphtha-range hydrocarbon feed according to any one of items 29 to 33, wherein the renewable stabilized naphtha-range hydrocarbon feed has a total content of olefins and naphthenes of 0.1 wt.-% to 8.0 wt.-%, such as 0.1 wt.-% to 6.5 wt.-%, 0.1 wt.-% to 6.0 wt.-%, 0.2 wt.-% to 5.5 wt.-%, 0.5 wt.-% to 5.5 wt.-%, 0.5 wt.-% to 5.0 wt.-%, 0.8 wt.-% to 5.0 wt.-%, 0.9 wt.-% to 5.0 wt.-%, 1.0 wt.-% to 5.0 wt.-%, 1.1 wt.-% to 5.0 wt.-%, or 1.2 wt.-% to 5.0 wt.-
  • renewable stabilized naphtha-range hydrocarbon feed according to any one of items 29 to 34, wherein the renewable stabilized naphtha-range hydrocarbon feed has a content of aromatics of 0.80 wt.-% or less, preferably 0.70 wt.-% or less, 0.60 wt.-% or less, 0.50 wt.-% or less, 0.40 wt.-% or less, 0.35 wt.-% or less, 0.30 wt.-% or less, 0.25 wt.-% or less, 0.20 wt.-% or less, or 0.15 wt.-% or less. 36.
  • renewable stabilized naphtha-range hydrocarbon feed according to any one of items 29 to 35, wherein the renewable stabilized naphtha-range hydrocarbon feed has a ratio between the content of naphthenes and the content of aromatics of 1 or more, preferably 10 or more, 50 or more, or 100 or more.
  • renewable stabilized naphtha-range hydrocarbon feed according to any one of items 29 to 36, wherein the renewable stabilized naphtha-range hydrocarbon feed has a total content of olefins, aromatics and naphthenes of
  • renewable stabilized naphtha-range hydrocarbon feed according to any one of items 29 to 37, wherein the renewable stabilized naphtha-range hydrocarbon feed has a content of oxygenates of 1000 wt.-ppm or less, preferably 700 wt.-ppm or less, 500 wt.-ppm or less, 300 wt.-ppm or less, 100 wt.-ppm or less, 80 wt.-ppm or less, 60 wt.-ppm or less, 50 wt.-ppm or less, 40 wt.-ppm or less, or 30 wt.-ppm or less.
  • oxygenates 1000 wt.-ppm or less, preferably 700 wt.-ppm or less, 500 wt.-ppm or less, 300 wt.-ppm or less, 100 wt.-ppm or less, 80 wt.-ppm or less, 60 wt.-ppm or less, 50 wt.-ppm or less, 40
  • renewable stabilized naphtha-range hydrocarbon feed according to any one of items 29 to 38, wherein the renewable stabilized naphtha-range hydrocarbon feed has a content of C17 and higher carbon number compounds of 1.0 wt.-% or less, such as 0.0 to 0.9 wt.-%, preferably 0.0 to 0.8 wt.-%, more preferably 0.0 to 0.5 wt.-% or 0.0 to 0.2 wt.-%.
  • IVR interventile carbon number range
  • renewable stabilized naphtha-range hydrocarbon feed according to any one of items 29 to 41, wherein the renewable stabilized naphtha-range hydrocarbon feed has an interdecile carbon number range (IDR) of 4.5 or less, preferably 4.0 or less, 3.5 or less, or 3.0 or less.
  • IDR interdecile carbon number range
  • renewable stabilized naphtha-range hydrocarbon feed according to any one of items 29 to 42, wherein the renewable stabilized naphtha-range hydrocarbon feed has an interquartile carbon number range (IQR) of 2.5 or less, preferably 2.0 or less, 1.8 or less, or 1.5 or less.
  • IQR interquartile carbon number range
  • renewable stabilized naphtha-range hydrocarbon feed according to any one of items 29 to 43, wherein the renewable stabilized naphtha-range hydrocarbon feed has a content of Cll and higher carbon number components of less than 5.0 wt.-%, preferably 4.5 wt.-% or less, 4.0 wt.-% or less, 3.5 wt.-% or less, 3.0 wt.-% or less, 2.5 wt.-% or less or 2.0 wt.-% or less.
  • renewable stabilized naphtha-range hydrocarbon feed according to any one of items 29 to 44, wherein the renewable stabilized naphtha-range hydrocarbon feed has a T95 temperature of 220°C or less, preferably 200°C or less, 180°C or less, 160°C or less, or 140°C or less.
  • renewable stabilized naphtha-range hydrocarbon feed according to any one of items 29 to 47, wherein the renewable stabilized naphtha-range hydrocarbon feed has an initial boiling point of 20°C or more, preferably 20°C to 60°C, such as 30°C to 50°C or 30°C to 45°C.
  • renewable stabilized naphtha-range hydrocarbon feed according to any one of items 29 to 48, wherein the renewable stabilized naphtha-range hydrocarbon feed has a T5 temperature of 40°C or more, preferably 45°C or more, 50°C or more, 55°C or more, or 60°C or more.
  • renewable stabilized naphtha-range hydrocarbon feed according to any one of items 29 to 49, wherein the difference between the T10 temperature and the T90 temperature of the renewable stabilized naphtharange hydrocarbon feed is less than 100°C, preferably less than 80°C, such as 20°C to 75°C, 30°C to 70°C, or 40°C to 70°C.
  • renewable stabilized naphtha-range hydrocarbon feed according to any one of items 29 to 50, wherein the renewable stabilized naphtha-range hydrocarbon feed has a total paraffins content of 90 wt.-% or more, preferably 92 wt.-% or more, 93 wt.-% or more, 94 wt.-% or more or 95 wt.-% or more.
  • renewable stabilized naphtha-range hydrocarbon feed according to any one of items 29 to 53, wherein the renewable stabilized naphtha-range hydrocarbon feed is obtainable by a method comprising subjecting an oxygenate bio-renewable feed to hydrotreatment comprising at least hydrodeoxygenation, and optionally to hydroisomerisation.
  • renewable stabilized naphtha-range hydrocarbon feed according to any one of items 29 to 55 obtainable by a method comprising : subjecting an oxygenate bio-renewable feed to hydrotreatment comprising at least hydrodeoxygenation to provide a hydrotreatment effluent, subjecting at least part of the hydrotreatment effluent to gas-liquid separation to provide a gaseous stream and a first liquid hydrocarbon stream, providing the first liquid hydrocarbon stream as a liquid hydrocarbon stream or subjecting at least part of the first liquid hydrocarbon stream to a further hydrotreatment comprising at least hydroisomerisation, followed by optional further gas-liquid separation, to provide at least a second liquid hydrocarbon stream as the liquid hydrocarbon stream, and feeding at least part of the liquid hydrocarbon stream to a first distillation column, preferably a first stabilisation column, to obtain a first overhead fraction and a stabilised heavy liquid hydrocarbon fraction, separating from the first overhead fraction at least a fuel gas fraction and a naphtha range fraction, refluxing a portion, preferably at least 50
  • renewable stabilized naphtha-range hydrocarbon feed according to item 56 wherein the hydrotreatment comprising at least hydrodeoxygenation further comprises hydroisomerisation.
  • the renewable stabilized naphtha-range hydrocarbon feed according to any one of items 29 to 57, having a content of C4 and lower carbon number compounds of 5.0 wt.-% or less, preferably 2.5 wt.-% or less, more preferably 2.0 wt.-% or less, even more preferably 1.5 wt.-% or less
  • a renewable thermal cracking effluent having a benzene content of 6.0 wt.-% or less, a total content of ethylene and propylene of 45.0 wt.-% or more and a carbon monoxide content of 0.25 wt.-% or less.
  • the renewable thermal cracking effluent according to item 60 having a benzene content of 0.01 wt.-% to 6.0 wt.-%, such as 0.1 wt.-% to 4.0 wt.- %, 0.1 wt.-% to 3.6 wt.-%, 0.1 wt.-% to 3.4 wt.-%, 0.1 wt.-% to 3.2 wt.- %, 0.1 wt.-% to 3.0 wt.-%, 0.1 wt.-% to 2.8 wt.-%, 0.1 wt.-% to 2.6 wt.- %, 0.2 wt.-% to 2.4 wt.-%, 0.3 wt.-% to 2.2 wt.-%, or 0.5 wt.-% to 2.0 wt.- % or less.
  • renewable thermal cracking effluent according to item 60 or 61, wherein the renewable thermal cracking effluent has a total content of ethylene and propylene of 45 wt.-% to 65 wt.-%, preferably 46.0 wt.-% to 65.0 wt.-%, 47.0 wt.-% to 65.0 wt.-%, 48.0 wt.-% to 65.0 wt.-%, 49.0 wt.- % to 65.0 wt.-%, 50.0 wt.-% to 60.0 wt.-%, or 50.0 wt.-% to 55.0 wt.-%.
  • renewable thermal cracking effluent according to any one of items 60 to 62, wherein the renewable thermal cracking effluent has a total content of C4 olefins of at least 5.0 wt.-%, such as 5.0 wt.-% to 20.0 wt.-%, preferably at least 8.0 wt.-%, at least 10.0 wt.-%, at least 11.0 wt.-%, at least 12.0 wt.-%, at least 12.6 wt.-%, at least 13.0 wt.-%, or at least 13.5 wt.-%.
  • C4 olefins of at least 5.0 wt.-%, such as 5.0 wt.-% to 20.0 wt.-%, preferably at least 8.0 wt.-%, at least 10.0 wt.-%, at least 11.0 wt.-%, at least 12.0 wt.-%, at least 12.6 wt.-%
  • renewable thermal cracking effluent according to any one of items 60 to 63, wherein the renewable thermal cracking effluent is the effluent of the thermal cracking furnace of step (b) of the method according to any one of items 1 to 25.
  • renewable thermal cracking effluent according to any one of items 60 to 64, wherein the renewable thermal cracking effluent has a carbon monoxide content of 0.23 wt.-% or less, preferably 0.21 wt.-% or less, 0.20 wt.-% or less, 0.19 wt.-% or less, 0.18 wt.-% or less, 0.17 wt.-% or less, 0.16 wt.-% or less, 0.15 wt.-% or less, 0.14 wt.-% or less, 0.13 wt.-% or less, 0.12 wt.-% or less, 0.11 wt.-% or less, 0.10 wt.-% or less, or 0.09 wt.- % or less.
  • renewable thermal cracking effluent according to any one of items 60 to 65, wherein the renewable thermal cracking effluent has a C4 monoolefin content of 6.0 wt.-% or more, preferably 6.5 wt.-% or more, 6.8 wt.-% or more, 7.0 wt.-% or more, 7.2 wt-% or more, or 7.4 wt.-% or more.
  • renewable thermal cracking effluent according to any one of items 60 to 66, wherein the renewable thermal cracking effluent has a C4 monoolefin content of at most 15.0 wt.-%, or at most 13.0 wt.-%.
  • renewable thermal cracking effluent according to any one of items 60 to 67, wherein the renewable thermal cracking effluent has a 1,3- butadiene content of at least 5.0 wt.-%, preferably at least 5.5 wt.-%, at least 6.0 wt.-% or at least 6.2 wt.-%.
  • renewable thermal cracking effluent according to any one of items 60 to 68, wherein the renewable thermal cracking effluent has a 1,3- butadiene content of at most 15.0 wt.-%, at most 13.0 wt.-%, or at most 11.0 wt.-%.
  • renewable thermal cracking effluent according to any one of items 60 to 69, wherein the renewable thermal cracking effluent has an isobutene content of least 2.0 wt.-%, preferably at least 2.4 wt.-%, at least 3.0 wt.-%, or at least 3.2 wt.-%.
  • renewable thermal cracking effluent according to any one of items 60 to 70, wherein the renewable thermal cracking effluent has an isobutene content of at most 10.0 wt.-%, at most 9.0 wt.-%, or at most 8.0 wt.-%.
  • renewable thermal cracking effluent according to any one of items 60 to 71, wherein the renewable thermal cracking effluent has a content of n-C4 monoolefins of 3.0 wt.-% or more, preferably 3.5 wt.-% or more, or 4.0 wt.-% or more.
  • renewable thermal cracking effluent according to any one of items 60 to 72, wherein the renewable thermal cracking effluent has a content of n-C4 monoolefins of at most 15.0 wt.-%, at most 12.0 wt.-%, or at most 10.0 wt.-%.
  • renewable thermal cracking effluent according to any one of items 60 to 73, wherein the renewable thermal cracking effluent has a total content of C2-C4 paraffins of more than 4.0 wt.-%, preferably 4.2 wt.-% or more, more preferably 4.3 wt.-% or more.
  • renewable thermal cracking effluent according to any one of items 60 to 74, wherein the renewable thermal cracking effluent has a total content of C2-C4 paraffins of at most 15.0 wt.-%, at most 12.0 wt.-% or at most 10.0 wt.-%.
  • renewable thermal cracking effluent according to any one of items 60 to 75, wherein the renewable thermal cracking effluent has a content of pyrolysis fuel oil (CIO and heavier compounds, abbreviated "PFO") of less than 1.5 wt.-%, preferably less than 1.2 wt.-%, more preferably less than 1.0 wt.-%.
  • CIO and heavier compounds abbreviated "PFO”
  • renewable thermal cracking effluent according to any one of items 60 to 76, wherein the renewable thermal cracking effluent has a toluene content in the range of from 0.2 wt.-% to 1.8 wt.-%, preferably 0.2 wt.-% to 1.6 wt.-%, 0.2 wt.-% to 1.4 wt.-%, 0.2 wt.-% to 1.2 wt.-%, 0.2 wt.-% to 1.0 wt.-%, 0.2 wt.-% to 0.9 wt.-%, 0.2 wt.-% to 0.8 wt.-%, 0.2 wt.-% to 0.7 wt.-%, or 0.3 wt.-% to 0.6 wt.-%.
  • renewable thermal cracking effluent according to any one of items 60 to 77, wherein the renewable thermal cracking effluent has a total content of ethylene and propylene of 50.0 wt.-% or more, a benzene content of 4.0 wt.-% or less, and a toluene content in the range of from 0.2 wt.-% to 0.6 wt.-% 79.
  • renewable thermal cracking effluent according to any one of items 60 to 78, wherein the renewable thermal cracking effluent has a total content of ethylene and propylene and total C4 olefins of 45 wt.-% to 80 wt.-%, preferably 50 wt.-% to 75 wt.-%, 50 wt.-% to 70 wt.-%, 50 wt.-% to 65 wt.- %, or 55 wt.-% to 65 wt.-%.
  • a biopolymer composition obtainable by the method according to item 27.
  • FIG. 1 illustrates linear interpolation for obtaining c_50 value.
  • contents and content ratios are provided on a weight basis.
  • i-paraffins also referred to as iso-paraffins
  • n-paraffins also referred to as normal-paraffins
  • Total paraffins content refers to the summed content of i-paraffins and n-paraffins.
  • olefins refer to linear or branched non-cyclic alkenes, including multiple unsaturated.
  • Naphthenes refer to cyclic non-aromatic branched or non-branched alkanes, alkenes or alkynes, including multiple unsaturated.
  • Aromatics refer to compounds having at least one aromatic ring.
  • n-paraffins, i-paraffins, olefins, naphthenes and aromatics can be determined using the PIONA method, which is a GCxGC analysis method, as published by Pyl et al in Journal of Chromatography A, 1218 (2011) 3217- 3223 for the GCxGC description.
  • the primary column and secondary column are preferably reversed to enhance separation and identification of the isoparaffins from n-paraffins.
  • the term "renewable” or “bio-based” or “bio-” refers to a material which is derived from renewable or biological sources in full or in part.
  • Carbon atoms of renewable or biological origin comprise a higher number of unstable radiocarbon ( 14 C) atoms compared to carbon atoms of fossil origin. Therefore, it is possible to distinguish between carbon compounds derived from renewable or biological sources or raw material and carbon compounds derived from fossil sources or raw material by analysing the ratio of 12 C and 14 C isotopes.
  • a particular ratio of said isotopes yielding the "biogenic carbon content” can be used as a "tag" to identify renewable carbon compounds and differentiate them from non-renewable carbon compounds.
  • the isotope ratio does not change in the course of chemical reactions. Examples of a suitable method for analysing the biogenic carbon content are DIN 51637 (2014), ASTM D6866 (2020) and EN 16640 (2017).
  • the content of carbon from biological or renewable sources is expressed as the biogenic carbon content meaning the amount of biogenic carbon in the material as a weight percent of the total carbon (TC) in the material.
  • the biogenic carbon content is determined in accordance with EN 16640 (2017).
  • the term “renewable” or “bio-based” or “bio-” preferably refers to a material having a biogenic carbon content in the range of from 1% to 100%.
  • the biogenic carbon content of the renewable stabilized naphtha-range hydrocarbon feed which may also be referred to as bio-based cracker feed is preferably more than 5 % and up to 100%, such as more than 20 %, more than 40%, more than 50 %, more than 60 % or more than 70 %, more than 80 %, more than 90 %, or more than 95 %, and may even be about 100 %.
  • the biogenic carbon content of the oxygenate bio-renewable feed is preferably more than 50 % and up to 100%, preferably more than 60 % or more than 70 %, preferably more than 80 %, more preferably more than 90 % or more than 95 %, even more preferably about 100 %.
  • the biogenic carbon content of the renewable thermal cracking effluent of the present invention may be below 1 %, but is preferably at least 1 % and up to 100 %, such as at least 2 %, at least 5 %, at least 10 %, at least 20 %, at least 40 %, at least 50 %, at least 75 %, at least 90 %, or about 100 %.
  • the biogenic carbon content of the effluent of the thermal cracking furnace of step (b), and of products and intermediates downstream the cracking step (b) may be below 1 %, but is preferably at least 1 % and up to 100 %, such as at least 2 %, at least 5 %, at least 10 %, at least 20 %, at least 40 %, at least 50 %, at least 75 %, at least 90 %, or about 100 %.
  • the biogenic carbon content of the light olefin(s) (fraction) and/or the bio-monomer and/or the biopolymer composition may be below 1 %, but is preferably at least 1 % and up to 100 %, such as at least 2 %, at least 5 %, at least 10 %, at least 20 %, at least 40 %, at least 50 %, at least 75 %, at least 90 %, or about 100 %.
  • test method standards referred to in this text are the latest versions available on December 1, 2021.
  • the method of the present invention comprises a step (a) of providing a renewable stabilized naphtha-range hydrocarbon feed, a step (b) of thermally cracking the renewable stabilized naphtha-range hydrocarbon feed in a thermal cracking furnace, optionally together with co-feed(s) and/or additive(s), and a step (c) of subjecting the effluent of the thermal cracking furnace of step (b) to a separation treatment to provide at least a light olefin(s) fraction.
  • the method of the present invention provides a light olefin(s) fraction.
  • the method may comprise further purification of the light olefin(s) fraction to provide one or more light olefins, preferably of industry grade or even polymer grade.
  • thermal cracking step The step (b) of thermally cracking may be referred to as "thermal cracking step”.
  • the renewable stabilized naphtha-range hydrocarbon feed preferably has an initial boiling point of 20°C or more, preferably within 20°C to 50°C. The initial boiling point is more preferably within 30°C to 45°C.
  • the renewable stabilized naphtha-range hydrocarbon feed preferably has a T95 temperature (95 vol- % recovered) of 220°C or less, preferably 200°C or less, 180°C or less, 160°C or less, or 140°C or less.
  • the renewable stabilized naphtha-range hydrocarbon feed may have a T99 temperature (99 vol-% recovered) of 220°C or less, preferably 200°C or less, 180°C or less, 160°C or less, or 140°C or less, or a final boiling point of 220°C or less, preferably 200°C or less, 180°C or less, or 160°C or less.
  • the difference between initial boiling point and T95 temperature (T95-IBP) of the renewable stabilized naphtha-range hydrocarbon feed is preferably at least 50°C, such as at least 80°C.
  • the difference between initial boiling point and T95 temperature may be 50°C to 155°C, preferably 60°C to 120°C, 60°C to 100°C or 65°C to 90°C.
  • T temperature(s), such as T95 temperature, are as determined in accordance with EN ISO 3405-2019.
  • EN ISO 3405-2019 refers to the determination of distillation characteristics at atmospheric pressure, suitable for products boiling between 0°C and 400°C.
  • An initial boiling point of more than 20°C improves the suitability of the stabilized naphtha-range hydrocarbon feed for cracking in conventional steam cracking procedures.
  • the initial boiling point exceeds 50°C, a large amount of usable hydrocarbons may be lost (i.e. not valorised), which is not desired.
  • stabilized in the expression “stabilized naphtha-range” means that the content of C4 and lower carbon number compounds is 5.0 wt.-% or less, preferably 2.5 wt.-% or less, more preferably 2.0 wt.-% or less, even more preferably 1.5 wt.-% or less.
  • the "renewable stabilized naphtha-range hydrocarbon feed” contains at least 98.5 wt.-% hydrocarbons, preferably at least 99.5 wt.-%. In other words, at least 98.5 wt.-% of the feed are made up of hydrocarbons.
  • hydrocarbons mean compounds containing only C and H (carbon atoms and hydrogen atoms). This means that at most 1.5 wt.-%, preferably at most 0.5 wt.-% of the hydrocarbon feed may be made up of non-hydrocarbon species, such as heteroatom containing impurities or free water (free water according to ASTM D1364).
  • the non-hydrocarbon species may specifically be free water and/or species containing carbon atoms, hydrogen atoms and a heteroatom, such as at least one of oxygen, nitrogen, sulphur or phosphorous.
  • a heteroatom such as at least one of oxygen, nitrogen, sulphur or phosphorous.
  • the thermal cracking step (b) may be a steam cracking step. Steam cracking is tolerant to possible impurities which are common in renewable material. In addition, the method of the present invention has shown to provide particularly good results when employing steam cracking.
  • the thermal cracking step (b) is conducted at a coil outlet temperature (COT) selected from the range from 780°C to 880°C, preferably from 800°C to 860°C, more preferably from 820°C to 850°C.
  • COT coil outlet temperature
  • the thermal cracking step (b) may be conducted at a coil outlet pressure (COP) selected from the range from 1.3 bar to 6.0 bar, preferably from 1.3 bar to 3.0 bar.
  • COP coil outlet pressure
  • a pressure value or range refers to absolute pressure, unless otherwise specified.
  • the thermal cracking step (b) is preferably conducted in the presence of a thermal cracking diluent.
  • a thermal cracking diluent Any conventional thermal cracking diluent(s) may be used in the thermal cracking step (b).
  • thermal cracking diluents comprise steam, molecular nitrogen (N2), or a mixture thereof. Dilution of the thermal cracker feed lowers the hydrocarbon partial pressure in the thermal cracking coils and favours formation of primary reaction products, such as ethylene and propylene.
  • the thermal cracking diluent preferably comprises steam.
  • the thermal cracking step (b) is preferably conducted in the presence of a thermal cracking diluent at dilution within a range from 0.10 to 0.85, preferably from 0.25 to 0.60, such as 0.35 to 0.55.
  • the dilution refers to a flow rate ratio between thermal cracking diluent and the total cracker feed (flow rate of thermal cracking diluent [kg/h] I flow rate of total cracker feed [kg/h]).
  • the total cracker feed refers to the renewable stabilized naphtharange hydrocarbon feed plus optional co-feed(s) and optional additive(s), but excluding diluent.
  • the individual components of the total cracker feed as well as the diluent(s) may be fed to the thermal cracking furnace as a pre-formed mixture, as separate streams or as a combination of separate stream(s) and pre-formed mixture(s).
  • the method may comprise a purification treatment to remove at least one of methyl acetylene, propadiene, CO, CO2 and C2H2, preferably at least one of CO, CO2 and C2H2, as a purification stage (c') in the step (c) of separating at least the light olefin(s) fraction from the effluent of the thermal cracking furnace of step (b).
  • the step (c) may comprise quenching and cooling the effluent of the thermal cracking furnace of step (b). Typically, at least a portion of CO, CO2, C2H2, or a combination thereof, is removed from the effluent of the thermal cracking furnace of step (b) during the quenching and cooling.
  • the step (c) comprises fractionating the effluent of the thermal cracking furnace of step (b).
  • the fractionation may comprise separating from the cracking effluent a fuel oil fraction, a PyGas fraction, a hydrogen fraction, a methane fraction, a fuel gas fraction, and the light olefin(s) fraction, such as a C2 fraction (ethylene fraction), C3 fraction (propylene fraction), and/or a C4 fraction.
  • the fractionation may be carried out in a single stage or as a series of fractionations, such as first separating a C2/C3 fraction and then recovering a C2 fraction and a C3 fraction by a second-stage fractionation.
  • the method comprises, in step (c), separating from the effluent of the thermal cracking furnace of step (b) a C2 fraction, or a C3 fraction, or both a C2 fraction and a C3 fraction, or a C2/C3 fraction comprising C2 and C3 as a light olefin(s) fraction, and optionally subjecting at least ethylene derived from the C2 fraction, at least propylene derived the C3 fraction, or both ethylene and propylene to a polymerisation treatment.
  • the ethylene and/or propylene may be derived from the C2 and/or C3 fraction by further purification treatment(s) to obtain polymer grade material.
  • a fraction rich in C2 hydrocarbons is separated and this fraction is then further separated at least into a fraction comprising ethene and a fraction comprising ethane.
  • Such separation of a fraction rich C2 hydrocarbons e.g. a fraction comprising 30 wt.-% to 100 wt.-%, preferably at least 40 wt.-% C2 hydrocarbons, may be forwarded to a C2 splitter to provide a fraction comprising ethene and a fraction comprising ethane.
  • a fraction rich in C3 hydrocarbons may be separated and this fraction is then further separated at least into a fraction comprising propene and a fraction comprising propane.
  • Such separation of a fraction rich C3 hydrocarbons may be forwarded to a C3 splitter to provide a fraction comprising propene and a fraction comprising propane.
  • the fraction rich C3 hydrocarbons may be separated after the fraction rich C2 hydrocarbons has been separated or may be separated in the same stage.
  • Each of these fraction may be recovered as a product fraction of the method or may be further purified or post-processes to give a product fraction of the method.
  • the method may comprise subjecting at least a portion of the effluent of the thermal cracking furnace of step (b) to a purification treatment (c') within step (c) to remove at least one of CO, CO2, or C2H2.
  • a purification treatment c'
  • This is particularly advantageous in embodiments where at least a portion of the cracking effluent is subjected to a polymerisation treatment.
  • CO, CO2, and C2H2 are polymerisation catalyst poisons and thus undesirable in a polymerisation process.
  • An absorbent, an adsorbent, a reactant, a molecular sieve and/or a purification catalyst may be used in the purification treatment to remove at least one of CO, CO2, or C2H2, and decreases the regeneration frequency of the active material.
  • the purification treatment to which at least a portion of the effluent of the thermal cracking furnace of step (b) may be subjected can be any purification treatment suitable for removing at least one of CO, CO2, or C2H2. Examples of such purification treatments are described in EP 2679656 Al, WO 2016023973 Al, WO 2003048087 Al, and US 2010331502 Al, all of which are incorporated herein by reference in their entirety.
  • the purification treatment comprises contacting at least a portion of the cracking effluent with an active material, such as an absorbent, an adsorbent, a purification catalyst, a reactant, a molecular sieve, or a combination thereof, to remove at least one of CO, CO2, or C2H2.
  • an active material such as an absorbent, an adsorbent, a purification catalyst, a reactant, a molecular sieve, or a combination thereof.
  • the active material may comprise, for example, copper oxide or a copper oxide catalyst, oxides of Pt, Pd, Ag, V, Cr, Mn, Fe, Co, or Ni optionally supported on alumina, Au/CeC optionally supported on alumina, zeolites, in particular type A and/or type X zeolites, alumina based absorbents or catalysts, such as a SelexsorbTM COS or SelexordTM CD, a molecular sieve comprising alumina, aluminosilicates, aluminophosphates or mixtures thereof, or any combination thereof.
  • copper oxide or a copper oxide catalyst oxides of Pt, Pd, Ag, V, Cr, Mn, Fe, Co, or Ni optionally supported on alumina, Au/CeC optionally supported on alumina, zeolites, in particular type A and/or type X zeolites, alumina based absorbents or catalysts, such as a SelexsorbTM COS or Selexor
  • the active material may comprise an adsorbent or adsorbents as described in WO 03/048087 Al on p. 11, 11 12 - p. 12, 11. 3; p. 12, 11. 18 - p. 15, 11. 29, and/or p. 17, 11. 21 - p. 21, 11. 2 and/or a molecular sieve or molecular sieves as described in WO 03/048087 Al on p. 21, 11. 3 - p. 22 11. 26.
  • the active material may comprise a purification catalyst or catalysts as described in US 2010/0331502 Al, paragraphs [0105] to [0116], or a molecular sieve or molecular sieves as described in US 2010/0331502 Al, paragraphs [0117] to [0119].
  • the active material may comprise a purification catalyst or catalysts as described in WO 2016/023973 Al, paragraph [0061], [0062], [0063], and/or [0064]
  • the purification treatment may be a purification treatment as described in EP 2679656 Al, paragraphs [0043] to [0082].
  • the purification treatment may be a purification treatment as described in US 2010/0331502 Al, paragraphs [0092] to [0119], and/or paragraph [0126], and/or Example 2.
  • the purification treatment may be a purification treatment as described in WO 2016/023973 Al, paragraphs [0056] to [0067].
  • the purification treatment may be a purification treatment as described in WO 03/048087 Al, p. 11, 11. 12 - p. 15, 11. 29, and/or p. 16, 11. 1 - p. 21, 11. 2, and/or p. 23, 11. 14 - p. 24, 11. 13, and/or Example 1 and/or Example 2.
  • the purification treatment comprises at least one of the following steps: i) contacting at least a portion of the cracking effluent with a CuO catalyst to remove oxygen, ii) contacting at least a portion of the cracking effluent with H2 to remove C2H2 by hydrogenation, iii) contacting at least a portion of the cracking effluent with a CuC catalyst to remove CO by oxidation, or iv) contacting at least a portion of the cracking effluent with a zeolitic molecular sieve to remove CO2.
  • the purification treatment may comprises removing secondary impurities, such as at least one of COS, H2S, or CS2, by contacting at least a portion of the cracking effluent with an activated alumina catalyst, such as SelexorbTM.
  • secondary impurities such as at least one of COS, H2S, or CS2
  • the method may comprise performing one or more further cracking operation(s) to provide further cracking effluent(s), wherein step (c) further comprises adding the further effluent(s) and/or fraction(s) thereof before and/or during the separation treatment.
  • the cracking effluent obtained in step (b) may be combined with other stream(s), such as effluent(s) from further cracking process(s) produced in other thermal cracking furnace(s), i.e. further cracking effluent(s) and/or fraction(s) thereof, in step (c).
  • the further cracking effluent(s) and/or fraction(s) thereof may simply be referred to as co-feed(s) of step (c).
  • (b) preferably amounts to 10 wt.-% to 100 wt.-%, preferably 20 wt.-% to
  • step (b) 100 wt.-%, or 90 wt.-% to 100 wt.-% relative to the summed amount of effluent of the thermal cracking furnace of step (b) and the co-feed(s) of step
  • the one or more further cracking operation(s) are preferably carried out in one or more further cracking furnace(s).
  • the one or more further cracking operation(s) may be thermal cracking operation(s) and/or cracking operation(s) other than thermal cracking, such as FCC (fluidized catalytic cracking).
  • the further cracking operation(s) may be carried out with any suitable feed, including fossil feed (crude oil-based feed), renewable feed or a combination thereof.
  • the further cracking operation(s) are preferably carried out under conditions differing from step (b) in at least one of total cracker feed composition and cracking condition(s), such as COT, COP, or dilution.
  • the further cracking effluent(s) may be subjected to purification, gas-liquid separation and/or fractionation before being added in step (c) or may be added as such, i.e. as crude effluent(s).
  • the addition may be carried out before the separation treatment of step (c).
  • the further cracking effluent(s) is/are subjected to the separation treatment. This option is particularly suitable if a crude effluent is added as the further effluent.
  • the addition may be carried during or after the separation treatment of step (c). In this case, it is favourable for the further cracking effluent to be at least partially subjected to purification, gas-liquid separation and/or fractionation before being added in step (c).
  • step (b) The thermal cracking in step (b) is preferably carried out in the presence of co-feed(s).
  • the content of the renewable stabilized naphtha-range hydrocarbon feed in the total cracker feed is in the range of from 10 wt.-% to 100 wt.-%, preferably 20 wt.-% to 100 wt.-%, 30 wt.-% to 100 wt.-%, 40 wt.-% to 100 wt.-%, 50 wt.-% to 100 wt.-%, 60 wt.-% to 100 wt.-%, 70 wt.-% to 100 wt.-%, 80 wt.-% to 100 wt.-%, or 90 wt.-% to 100 wt.-%.
  • the upper limit may also be 90 wt.-% or 80 wt.-%, i.e. the content may for example be in the range of from 10 wt.-% to 90 wt.-% or from 10 wt.-% to 80 wt.-%.
  • the total cracker feed may consist of the renewable stabilized naphtha-range hydrocarbon feed, i.e. the content thereof may be 100 wt.-%.
  • the co-feed(s) may comprise a fossil hydrocarbon co-feed.
  • Fossil co-feeds in particular fossil naphtha, are readily available and highly suitable for thermal cracking.
  • the "fossil hydrocarbon co-feed” contains at least 98.5 wt.-% hydrocarbons, preferably at least 99.5 wt.-%. In other words, at least 98.5 wt.-% of the co-feed are made up of hydrocarbons. This means that at most 1.5 wt.-%, preferably at most 0.5 wt.-% of the hydrocarbon cofeed may be made up of non-hydrocarbon species, such as heteroatom containing impurities, and in particular sulphur-containing impurities.
  • the co-feed(s) comprise a naphtha range feed since this provides high compatibility with the renewable stabilized naphtha-range hydrocarbon feed.
  • the renewable stabilized naphtha-range hydrocarbon feed is a well-defined (narrow-range) feed, it is preferable to employ a narrow-range co-feed, such as fossil naphtha, in order to make full use of the benefits of the present invention.
  • a particularly preferred co-feed is light naphtha, specifically fossil light naphtha.
  • the light naphtha preferably boils in the range of from 20°C (IBP) to 120°C (FBP), such as from 30°C (IBP) to 90°C (FBP).
  • the total cracker feed preferably has a sulphur content in the range of from 20 to 300 ppm by weight, preferably 20 to 250 ppm by weight, more preferably 20 to 100 ppm by weight, and even more preferably 50 to 65 ppm by weight.
  • the sulphur may be incorporated in the total cracker feed by using a sulphur-containing co-feed, such as a fossil hydrocarbon feed.
  • the sulphur may also originate, in part or in total, from sulphur-containing additive(s), including conventional cracking additive(s).
  • any conventional thermal cracking additive(s) may be added to the renewable stabilized naphtha-range hydrocarbon feed of the present disclosure, to optional co-feed(s) or to a pre-formed total cracker feed or be co-fed to the thermal cracking furnace or may be added to thermal cracking diluent and thus fed to the thermal cracking furnace.
  • thermal cracking additives examples include sulphur containing species (sulphur additives), such as dimethyl disulphide (DMDS), or carbon disulphide (CS2).
  • sulphur additives such as dimethyl disulphide (DMDS), or carbon disulphide (CS2).
  • DMDS is a particularly preferred sulphur additive.
  • Sulphur additive(s) may be mixed with the renewable stabilized naphtha-range hydrocarbon feed, with optional co-feed(s) or with a pre-formed total cracker feed before feeding to the thermal cracking furnace.
  • sulphur additive(s) may be added by injecting into the thermal cracking furnace a thermal cracking diluent, preferably steam, comprising sulphur additive(s).
  • the step (a) of providing the stabilized naphtha-range hydrocarbon feed may for example comprise subjecting an oxygenate bio-renewable feed to hydrotreatment comprising at least hydrodeoxygenation, and to optional subsequent further hydrotreatment comprising at least hydroisomerisation, and conducting gas-liquid separation(s) after the hydrotreatment(s) to provide liquid hydrocarbon stream(s) and gaseous stream(s).
  • the optionally isomerised liquid hydrocarbon stream may be subjected to fractionation, from which at least the renewable stabilized naphtha-range hydrocarbon feed is recovered.
  • fractions may be recovered from the fractionation, including but not limited to a fuel gas fraction, a diesel range fraction, aviation fuel range fraction, a marine fuel fraction and an electrotechnical fluid fraction.
  • a propane fraction may be recovered at least from the gaseous stream(s) separated from the liquid hydrocarbon stream(s).
  • An exemplary aviation fuel range fraction may boil within a range from 100°C-300°C, such as within 150°C-300°C.
  • An exemplary gasoline fuel range fraction may boil within a range from 25°C-220°C.
  • An exemplary diesel fuel range fraction may boil within a range from 160°C-380°C.
  • An exemplary marine fuel range fraction may boil within 180°C-600°C.
  • a naphtha range fraction as disclosed herein may refer to a fraction having an initial boiling point of more than 0°C, preferably more than 20°C or more than 30°C, and a T95 temperature of 220°C or less, preferably 200°C or less, 180°C or less, 160°C or less, 140°C or less.
  • the naphtha range fraction may have a T99 temperature of 220°C or less, preferably 200°C or less, 180°C or less, 160°C or less, 140°C or less, or a final boiling point of 220°C or less, preferably 200°C or less or 180°C or less.
  • the boiling characteristics in the present invention such as the T95 temperature (95 vol-% recovered), the T99 temperature (99 vol-% recovered), the final boiling point, the initial boiling point, the T5 temperature (5 vol-% recovered) and the T10 temperature (10 vol-% recovered) are as determined in accordance with EN ISO 3405-2019.
  • the step (a) in the above embodiment preferably may comprise the further hydrotreatment comprising at least hydroisomerisation subsequent to the hydrotreatment comprising at least hydrodeoxygenation (HDO), and/or may comprise hydroisomerisation as a part of the hydrotreatment comprising at least HDO.
  • HDO hydrodeoxygenation
  • hydroisomerisation may be carried out in a separate further hydrotreatment after the hydrotreatment comprising at least HDO.
  • hydroisomerisation may be carried out as a part of the hydrotreatment comprising at least HDO, for example by means of a catalyst or catalyst system achieving both hydrodeoxygenation and hydroisomerisation in a single step.
  • hydrotreatment effluent may be subjected to gas-liquid separation to provide a gaseous stream and a first liquid hydrocarbon stream. At least part of the first liquid hydrocarbon stream may be provided as the liquid hydrocarbon stream mentioned above. Alternatively or in addition, at least part of the liquid hydrotreatment effluent stream may be subjected, in a subsequent stage, to the further hydrotreatment comprising at least hydroisomerisation to provide, preferably after gas-liquid separation, a second liquid hydrocarbon stream which may be provided as the liquid hydrocarbon stream mentioned above.
  • the gaseous stream obtained in a second gas-liquid separation may be combined and processed together with the gaseous stream obtained in the first gas-liquid separation.
  • Condensable hydrocarbons if any, may be separated from the gaseous stream(s), and combined with the liquid hydrocarbon stream.
  • At least a part of the first liquid hydrocarbon stream and/or of the second liquid hydrocarbon stream may be recycled back to the hydrotreatment comprising at least hydrodeoxygenation. Such recycling may be suited to achieve temperature control.
  • the above-mentioned gaseous stream(s) may be subjected to a propane separation process to provide a stream enriched in propane and a stream depleted in propane.
  • At least part of the propane contained in the stream enriched in propane may be subjected to dehydrogenation, preferably catalytic dehydrogenation, to produce propylene.
  • Propane (or a stream enriched in propane) may also be recovered from a stabilisation stage and subjected to such a dehydrogenation.
  • the propane (or a stream enriched in propane) recovered from a stabilisation stage may be subjected to dehydrogenation in a separate reactor or may be combined with propane (or a stream enriched in propane) separated after hydrotreatment so as to improve overall yields of light olefins per unit oxygenate biorenewable feed to hydrotreatment.
  • such a C3-rich stream i.e. the stream enriched in propane recovered after hydrotreatment, the stream recovered from stabilisation or a combined stream
  • thermal cracking such as steam cracking, in a separate furnace.
  • the method may further comprise subjecting the heavy liquid hydrocarbon fraction to further fractionation to provide at least an aviation fuel range fraction and a bottoms fraction.
  • a suitable method for fractionation, as well as usable fractionation cut-offs, resulting fractions and uses thereof are set forth in WO 2021/094656 Al, the content of which is herewith incorporated in its entirety.
  • the bottoms fraction is referred to as an electrotechnical fluid.
  • Each of the diesel range fraction, the aviation fuel range fraction, heavy liquid hydrocarbon fraction, the aviation fuel range fraction and the bottoms fraction may individually have an iso-paraffins content of at least 65 wt.-%, preferably at least 70 wt.-%, at least 75 wt.-%, at least 80 wt.-%, at least 85 wt.-% or at least 90 wt.-%.
  • the iso-paraffins content is calculated relative to total diesel range fraction or respective other fraction.
  • High isomerisation degree of the fractions, in particular of the diesel or aviation fuel range fraction indicates that the production process was carried out in highly isomerising mode, e.g. under severe isomerisation conditions. In such a case, the yield of naphtha range hydrocarbons tends to be higher, and the naphtha range fraction also tends to have higher iso-paraffins content. This improves overall yield of the process of the invention.
  • the above-mentioned stage of subjecting at least part of the liquid hydrocarbon stream to fractionation and recovering at least the renewable stabilized naphtha-range hydrocarbon feed preferably comprises a stage of subjecting at least part of the liquid hydrocarbon stream to fractionation to provide a naphtha range fraction and subjecting the naphtha range fraction to stabilization.
  • the stabilisation may comprise removing, preferably by means of a distillation technique, at least part of components boiling below 20°C, preferably removing at least part of components boiling below 25°C, removing at least part of components boiling below 30°C, removing at least part of components boiling below 40°C or removing at least part of components boiling below 50°C.
  • optional additional treatments such as stripping with N2, H2, or steam, to separate gases and impurities into the gaseous phase, may be performed on the liquid stream(s) during the fractionation stage.
  • the stabilisation stage may form a part of the fractionation from which the naphtha range fraction is recovered. Alternatively, or in addition, the stabilisation stage may be carried out as a separate stage after fractionation, i.e. removing the respective components from the recovered naphtha range fraction.
  • distillation may refer to any type of distillation, i.e. also to stripping, flashing, and any other similar separating operations based on differences in the vapour pressure of the components. Selecting suitable feed rates, operating temperatures, pressures, equipment type and design, and other engineering details for the present fractionation disclosure will be within capabilities of a person skilled in the art.
  • the above-mentioned heavy liquid hydrocarbon fraction and/or diesel range fraction may alternatively have an iso-paraffins content of less than 65 wt.- %.
  • the above-mentioned bottoms fraction may be subjected to a further thermal cracking, preferably steam cracking.
  • This further cracking stage is preferably carried out separate from the thermal cracking step (b), i.e. in a different furnace and/or at a different time.
  • the cracking conditions may be different from those employed in step (b), but the same conditions as useable in step (b) may be employed as well.
  • the step (a) may comprise hydrotreatment of an oxygenate bio-renewable feed, such as an oil and/or fat of plant origin, animal origin or other biological origin. That is, as already pointed out above, the renewable stabilized naphtha-range hydrocarbon feed may be based on a hydrotreated oxygenate feed.
  • an oxygenate bio-renewable feed such as an oil and/or fat of plant origin, animal origin or other biological origin. That is, as already pointed out above, the renewable stabilized naphtha-range hydrocarbon feed may be based on a hydrotreated oxygenate feed.
  • the step (a) may comprise a step (a') of pre-treating bio-renewable oil(s) and/or fat(s) for reducing contaminants in the oil(s) and/or fat(s) to produce the oxygenate bio-renewable feed.
  • the oil(s) and/or fat(s) may be employed as the oxygenate bio-renewable feed without pre-treatment.
  • the pre-treatment step (a') may be a step of reducing contaminants containing S, N and/or P in the oil(s) and/or fat(s) to produce the oxygenate bio-renewable feed.
  • the pre-treatment step (a') may be a step of reducing metal-containing contaminants in the oil(s) and/or fat(s) to produce the oxygenate bio-renewable feed.
  • the pretreatment step reduces content of one or more of S, N, P, alkali metals, alkaline earth metals, Si, Al, Fe, Zn, Cu, Mn, Cd, Pb, As, Cr, Ni, V, Sn.
  • Suitable methods for carrying out the pre-treatment step (a') comprise one or more selected from washing, degumming, bleaching, distillation, fractionation, rendering, heat treatment, evaporation, filtering, adsorption, hydrotreatment such as hydrodeoxygenation, centrifugation or precipitation.
  • These pre-treatment methods are simple and effective methods for removing the potentially catalyst-poisoning S, N and P contaminants as well as metal contaminants (metals and/or metal compounds), including metalloid contaminants, such as Si-containing impurities.
  • the pre-treatment step (a') may comprise, in the alternative or in addition, at least one of partial hydrogenation, partial deoxygenation, hydrolysis and transesterification.
  • the oxygenate bio-renewable feed may comprise fatty acid ester(s) of glycerol.
  • the effluent of hydrotreatment and optional isomerisation is subjected to fractionation, preferably after gas-liquid separation.
  • the fractionation may directly yield the renewable stabilized naphtha-range hydrocarbon feed or may further be treated, such a stabilized, to provide the renewable stabilized naphtha-range hydrocarbon feed.
  • the total feed which may be subjected to hydrotreatment in step (a) preferably comprises a hydrotreatment diluent comprising paraffinic hydrocarbons in addition to the oxygenate bio-renewable feed.
  • a hydrotreatment diluent is particularly suited for temperature control during hydrotreatment, specifically during hydrodeoxygenation.
  • the hydrotreatment diluent may comprise at least one of recycled paraffinic hydrocarbons from the hydrotreatment effluent and/or isomerisation effluent, renewable hydrocarbons obtained by Fischer-Tropsch synthesis using bio-syngas, and fossil-based hydrocarbons.
  • the hydrotreatment diluent comprises recycled paraffinic hydrocarbons from the hydrotreatment effluent and/or isomerisation effluent.
  • the hydrotreatment feed preferably contains at least 2 wt.-% of the oxygenate bio-renewable feed, such as 2 wt.-% to 100 wt.-%, preferably 3 wt.-%, at least 4 wt.-%, at least 5 wt.-%, at least 6 wt.-%, at least 7 wt.-%, at least 8 wt.-%, at least 9 wt.-%, at least 10 wt.-%, at least 11 wt.-%, at least 12 wt.-%, at least 15 wt.-%, at least 20 wt.-%, at least 25 wt.-%, at least 50 wt.-%, at least 75 wt.-%, at least 90 wt.-% or at least 95 wt.-%, or at least 99 wt.-%.
  • the oxygenate bio-renewable feed such as 2 wt.-% to 100 wt.-%
  • the feed which is subjected to hydrotreatment in step (a) may contain 99 wt.-% or less of a oxygenate bio-renewable feed, such as 2 wt.- % to 99 wt.-%, preferably 90 wt.-% or less, 75 wt.-% or less, 50 wt.-% or less, 40 wt.-% or less, 35 wt.-% or less, 30 wt.-% or less, 25 wt.-% or less, 20 wt.-% or less, 15 wt.-% or less, or 10 wt.-% or less.
  • a oxygenate bio-renewable feed such as 2 wt.- % to 99 wt.-%, preferably 90 wt.-% or less, 75 wt.-% or less, 50 wt.-% or less, 40 wt.-% or less, 35 wt.-% or less, 30 wt.-% or less, 25
  • the hydrotreatment feed preferably contains 10 wt.-% to 98 wt.-% of the recycled paraffinic hydrocarbons from the hydrotreatment step, preferably at least 25 wt.-%, at least 40 wt.-%, at least 50 wt.-%, at least 60 wt.-%, at least 70 wt.-%, at least 75 wt.-%, at least 80 wt.-%, at least 85 wt.-%, at least 90 wt.-%, or at least 92 wt.-%.
  • the hydrotreatment feed may similarly contain 98 wt.-% or less, 95 wt.-% or less, 92 wt.-% or less, 90 wt.-% or less, 85 wt.-% or less, 80 wt.-% or less, 70 wt.-% or less, 60 wt.-% or less, 40 wt.-% or less or 25 wt.-% or less of the recycled paraffinic hydrocarbons from the hydrotreatment step, such as 10 wt.-% to 25 wt.-%.
  • the recycled product from the hydrotreatment step is preferably a hydrocarbon, but may similarly be a material which is only partially deoxygenated and then recycled into the hydrotreatment step for further deoxygenation.
  • the hydrotreatment may involve, in addition to hydrodeoxygenation (HDO), decarbonylation and/or decarboxylation. These reactions give carbon monoxide or carbon dioxide and a hydrocarbon chain having one carbon less than the original chain.
  • the hydrotreatment preferably HDO, may for example be carried out by feeding hydrogen and the natural fat or derivative thereof (co-currently or counter-currently) through a catalyst bed.
  • the hydrotreatment preferably HDO, is preferably carried out at a temperature between 100°C and 500°C, preferably between 250°C and 350°C, more preferably between 280°C and 345°C, most preferably between 280°C and 310°C.
  • a preferred pressure is 1 MPa to 20 MPa, a more preferable one 3 MPa to 10 MPa, the most preferable one being 4 MPa to 8 MPa.
  • the hydrotreatment may be carried out in the presence of a hydrogenation catalyst containing one or more metals from Groups 6 to 10 of the Periodic Table (IllPAC 1990), preferably a supported catalyst, more preferably the above-mentioned one or more metals supported on alumina and/or silica.
  • a hydrogenation catalyst containing one or more metals from Groups 6 to 10 of the Periodic Table (IllPAC 1990), preferably a supported catalyst, more preferably the above-mentioned one or more metals supported on alumina and/or silica.
  • Preferred hydrogenation catalysts are alumina and/or silica supported Pd, Pt, Ni, NiMo, or CoMo.
  • the most preferred catalysts are NiMo/AhOs and C0M0/AI2O3 in sulphided form.
  • hydrotreatment is meant to encompass removal of oxygen from organic oxygen compounds as water i.e. hydrodeoxygenation (HDO), removal of sulphur from organic sulphur compounds as dihydrogen sulphide (H2S), i.e. hydrodesulphurisation (HDS), removal of nitrogen from organic nitrogen compounds as ammonia (NH3), i.e. hydrodenitrogenation (HDN), removal of halogens, for example chlorine from organic chloride compounds as hydrochloric acid (HCI), i.e. hydrodechlorination (HDCI), removal of metals by hydrodemetallization, and hydrogenation of unsaturated bonds if present.
  • HDO hydrodeoxygenation
  • HDS hydrodesulphurisation
  • NH3 ammonia
  • HDN hydrodenitrogenation
  • halogens for example chlorine from organic chloride compounds as hydrochloric acid (HCI), i.e. hydrodechlorination (HDCI), removal of metals by hydrodemetallization, and hydrogenation of unsaturated bonds if
  • hydrocracking may be performed to increase yield of naphtha range hydrocarbons, which is beneficial for the overall process.
  • the optional isomerisation results in higher yield of naphtha-range hydrocarbons, thus improving the overall yield of the method.
  • the method can be adjusted towards production of other fractions, in particular at least a diesel range fraction, while making use of the naphtha range fraction as a side product. In this case, it is preferable to recover a diesel range fraction in addition to the naphtha range fraction.
  • the optional isomerisation may be carried out at a temperature selected from the range 200 °C to 500 °C, preferably 280 °C to 400 °C, and at a pressure selected from the range 20-150 bar (absolute), preferably 30-100 bar.
  • the isomerization (isomerisation treatment) may be performed in the presence of known isomerization catalysts, for example, catalysts containing a molecular sieve and/or a metal selected from Group VIII of the Periodic Table and a carrier.
  • the isomerization catalyst is a catalyst containing SAPO-11 or SAPO-41 or ZSM- 22 or ZSM-23 or ferrierite and Pt, Pd, or Ni and AI2O3 or SiC .
  • Typical isomerisation catalysts are, for example, Pt/SAPO-ll/A Os, Pt/ZSM- 22/AI2O3, Pt/ZSM-23/AI 2 O3 and/or Pt/SAPO-ll/SiC .
  • Catalyst deactivation may be reduced by the presence of molecular hydrogen in the isomerisation treatment. Therefore, the presence of added hydrogen in the isomerisation treatment is preferred.
  • the hydrotreatment catalyst(s) and the isomerization catalyst(s) may not be in contact with the reaction feed (the oxygenate biorenewable feed and/or the deoxygenated stream derived therefrom) at the same time.
  • the hydrotreatment and the isomerisation treatment are conducted in separate reactors.
  • the isomerisation may be a high severity isomerisation.
  • High severity isomerisation in the present invention is meant to refer to any technologies achieving high iso-paraffins content in the naphtha fraction, typically 50-60 wt.-% or 55-60 wt.-%.
  • High i-paraffins content (and high ratio between i- paraffins and n-paraffins) can particularly be achieved for paraffins having longer chains, i.e. having carbon numbers near the upper carbon number limit of the naphtha range.
  • triglyceride-based biomass as an oxygenate bio-renewable feed.
  • a hydrotreatment catalyst such as NiMo catalyst supported on AI2O3 under hydrogen pressure.
  • Sulphur components are preferably added to the inlet stream to keep the catalyst in the sulphided state.
  • triglyceride oils and fatty acids are converted to n-alkanes with minor amounts of branched alkanes (usually in the range of 1 wt.-%).
  • oxygen content can be removed under the form of water (hydrodeoxygenation), carbon monoxide (decarbonylation) and carbon dioxide (decarboxylation).
  • Oxygen removal by decarbonylation and decarboxylation consumes less hydrogen compared to hydrodeoxygenation but causes the resulting alkane to have one carbon atom less compared to the original fatty acid chain.
  • isomerisation is carried out over a molecular sieve impregnated with platinum, e.g. Pt/ZSM- 22.
  • the method of the present invention may further comprise derivatisation of at least part of the light olefin(s) to obtain one or more derivate(s) of the light olefin(s) as bio-monomer(s), such as acrylic acid, acrylonitrile, acrolein, propylene oxide, ethylene oxide, 1,4-butanediol, 1,2-butanediol, 1,3- butanediol, 2,3-butanediol, adiponitrile, hexamethylene diamine (HMDA), hexamethylene diisocyanate (HDI), (methyl)methacrylate, ethylidene norboreen, 1,5,9-cyclododecatriene, sulfolane, 1,4-hexadiene, tetrahydrophthalic anhydride, valeraldehyde, 1,2-butyloxide, n-butyl mercaptan, o-sec-
  • the method of the present invention may further comprise a step (d) of (co)polymerizing at least one of the light olefin(s) separated in step (c) and/or at least one of the above-mentioned bio-monomer(s), optionally together with other (co)monomer(s) and/or after optional further purification, to produce a biopolymer composition.
  • acrylic acid is meant to include any type of acrylic-based monomers, e.g. those based on (meth)acrylic acid, (meth)acrylic acid esters, and/or (meth)acrylic acid salts.
  • Acrylic polymers are meant to include any type of acrylic-based polymers, e.g. those containing structural units derived from (meth)acrylic acid, (meth)acrylic acid esters, and/or (meth)acrylic acid salts
  • the light olefins and/or bio-monomers may be (co)polymerized to give a biopolymer composition
  • a biopolymer composition comprising for example polybutadiene, styrenebutadiene rubber, nitrile rubber, polychloroprene, acrylonitrile butadiene styrene resin (ABS), styrene butadiene latex, TPE, nylon, such as nylon 6,6, polyurethane, methyl methacrylate-butadiene-styrene (MBS), nitrile barrier resin, butyl rubber, polyisobutylene, methyl methacrylate (MMA), MTBE/ETBE, polyolefin (co)polymers, polybutene-1, polypropylene (PP), ethylene-propylene-copolymer (EPM), polyether, polyether polyol, polyester, polymer or oligomer surfactant or ethylene-propylene-diene
  • the derivatisation may, for example, comprise at least one of oxidation and ammoxidation. Oxidation is preferably carried out by gas phase oxidation.
  • the polymerisation may be carried out in the presence of a polymerisation catalyst.
  • the polymerisation may be initiated by means of a polymerization initiator.
  • the biopolymer composition may be further processed to produce a sanitary article, a construction material, a packaging material, a coating composition, a paint, a decorative material, such as a panel, an interior part of a vehicle, such as an interior part of a car, a rubber composition, a tire or tire component, a toner, a personal health care article, a part of a consumer good, a part or a housing of an electronic device, a film, a moulded product, a gasket, optionally together with other components.
  • an acrylic polymer may be a water-absorbing polymer which may be further processed to produce a sanitary article, such as a diaper, a sanitary napkin, an incontinence draw sheet.
  • the present invention furthermore relates to a biopolymer composition obtainable by the embodiment of the method of the present invention including polymerisation of light olefin(s) and/or derivative(s) thereof.
  • the present invention furthermore relates to a renewable stabilized naphtharange hydrocarbon feed for thermal cracking.
  • the renewable stabilized naphtha-range hydrocarbon feed has a content of naphthenes in the range of from 0.1 wt.-% to 10.0 wt.-% based on the total weight of the renewable stabilized naphtha-range hydrocarbon feed. More preferably, the renewable stabilized naphtha-range hydrocarbon feed has a content of naphthenes of 0.2-10.0 wt.-%, such as 0.5-8.0 wt.-%, 0.5-6.0 wt.-%, 0.6 to 5.8 wt.-%, 0.8 to 5.8 wt.-%, 1.0 to 5.6 wt.-% or 1.2 to 5.6 wt.-%. Naphthenes convert easily to aromatics, which are compounds possibly reacting to coke but not to desired products. Thus, it is preferred that the naphthenes content is low in the renewable stabilized naphtha-range hydrocarbon feed.
  • the renewable stabilized naphtha-range hydrocarbon feed has a content of olefins of 0.50 wt.-% or less, preferably 0.40 wt.-% or less, 0.30 wt.-% or less, 0.25 wt.-% or less, 0.20 wt.-% or less, 0.15 wt.-% or less, 0.12 wt.-% or less, 0.10 wt.-% or less, 0.07 wt.-% or less, or 0.05 wt.-% or less.
  • Olefins are undesired components in the renewable stabilized naphtharange hydrocarbon feed of the present invention.
  • olefins have a strong coking tendency which is even higher than that of aromatics and, therefore, the content of olefins should be kept low.
  • the olefins content may be 0%, i.e. no detectable amounts of olefins contained.
  • the renewable stabilized naphtha-range hydrocarbon feed has a total content of olefins and naphthenes in the range from 0.1 wt.-% to 10.0 wt.-%.
  • the total content olefins and naphthenes refers to the summed content of olefins and naphthenes based on the total weight of the renewable stabilized naphtha-range hydrocarbon feed.
  • the renewable stabilized naphtha-range hydrocarbon feed has a total content of olefins and naphthenes of 0.1 wt.-% to 8.0 wt.-%, such as 0.1 wt.-% to 6.5 wt.-%, 0.1 wt.-% to 6.0 wt.-%, 0.2 wt.-% to 5.5 wt.-%, 0.5 wt.-% to 5.5 wt.-%, 0.5 wt.-% to 5.0 wt.-%, 0.8 wt.-% to 5.0 wt.-%, 0.9 wt.-% to 5.0 wt.-%, 1.0 wt.-% to 5.0 wt.-%, 1.1 wt.-% to 5.0 wt.-%, or 1.2 wt.-% to 5.0 wt.-%.
  • the renewable stabilized naphtha-range hydrocarbon feed has a content of aromatics of 0.80 wt.-% or less, preferably 0.70 wt.-% or less, 0.60 wt.-% or less, 0.50 wt.-% or less, 0.40 wt.-% or less, 0.35 wt.-% or less, 0.30 wt.-% or less, 0.25 wt.-% or less, 0.20 wt.-% or less, or 0.15 wt.- % or less.
  • Aromatics such as benzene, do not react into desired products. Rather, they tend to react to coke (i.e. they are coke precursors). Their presence in the feed thus reduces the yield of the desired products and their content in the feed should be low.
  • the content of aromatics is preferably low and may be 0.00%.
  • the content of aromatics may be determined by the PIONA analysis.
  • the renewable stabilized naphtha-range hydrocarbon feed has a ratio between the content of aromatics and the content of naphthenes (content by weight of naphthenes divided by content by weight of aromatics) of 1 or more, preferably 10 or more, 50 or more, or 100 or more.
  • Both naphthenes and aromatics tend to increase the yield of cyclic compounds in thermal cracking.
  • naphthenes are preferred over aromatics.
  • the ratio has no specific upper limit and the ratio may even be infinite in case no aromatics are contained.
  • the renewable stabilized naphtha-range hydrocarbon feed has a total content of olefins, aromatics and naphthenes of 0.1 wt.-% to 10.0 wt.- %, preferably 0.1 wt.-% to 8.0 wt.-%, 0.1 wt.-% to 6.5 wt.-%, 0.2 wt.-% to 6.0 wt.-%, 0.5 wt.-% to 5.5 wt.-%, 0.5 wt.-% to 5.0 wt.-%, 0.8 wt.-% to 5.0 wt.-%, 0.9 wt.-% to 5.0 wt.-%, 1.0 wt.-% to 5.0 wt.-%, 1.1 wt.-% to 5.0 wt.-%, or 1.2 wt.-% to 5.0 wt.-%.
  • Naphthenes, aromatics and olefins are coke precursors and their content should be low. However, since it may be laborious to strongly reduce the content of all of these components, certain contents thereof can be tolerated. Nevertheless, their total content may be down to 0%, including 0%.
  • the renewable stabilized naphtha-range hydrocarbon feed has a content of oxygenates of 1000 wt.-ppm or less, preferably 700 wt.-ppm or less, 500 wt.-ppm or less, 300 wt.-ppm or less, 100 wt.-ppm or less, 80 wt.-ppm or less, 60 wt.-ppm or less, 50 wt.-ppm or less, 40 wt.-ppm or less, or 30 wt.-ppm or less.
  • Oxygenates mean herein molecules containing carbon and hydrogen and further containing covalently bound oxygen in the structure (molecule). In the present invention, low amounts of oxygenates are preferred, including no oxygenates.
  • a low-oxygenate co-feed e.g. a fossil hydrocarbon co-feed
  • higher values such as from 100 wt.-ppm to 1000 wt.- ppm may be used.
  • the effort for minimizing oxygenate content is minimized which increases overall efficiency of the process.
  • the renewable stabilized naphtha-range hydrocarbon feed of the present invention is a naphtha range feed, the number of possible oxygenates is limited.
  • the content of oxygenates is determined based on ASTM D7423 (determining C2-C5 oxygenates by GC- FID, i.e.
  • oxygenates may be present in a renewable stabilized naphtha-range hydrocarbon feed of the present invention: ETBE (ethyl t-butyl ether), MTBE (methyl t-butyl ether), TAME (t-amyl methyl ether), DIPE (diisopropyl ether), propylether, isobutyraldehyde, butyraldehyde, isobutanol, n-butanol, secbutanol, tert-butanol, methanol, acetone, vinyl acetate, ethyl acetate, MEK (methyl ethyl ketone), isovaleraldehyde, valeraldehyde, ethanol, isopropanol, n-propanol, allylalcohol, diethylether, acetal
  • the renewable stabilized naphtha-range hydrocarbon feed has a content of C17 and higher carbon number compounds of 1.0 wt.-% or less, such as 0.0 to 0.9 wt.-%, preferably 0.0 to 0.8 wt.-%, more preferably 0.0 to 0.5 wt.-%, or 0.0 to 0.2 wt.-%.
  • the renewable stabilized naphtha-range hydrocarbon feed has a carbon range of 10 or less, preferably 8 or less, 7 or less, 6 or less, or 5 or less.
  • the carbon range is preferably 1 or more, 2 or more, or 3 or more.
  • the carbon range is preferably in a range of from 1 to 10, such as from 2 to 10, 3 to 10, 3 to 8, 3 to 7, 2 to 6, 3 to 6, 2 to 5, or 3 to 5.
  • the carbon range is more sensitive to low amounts of outliers in the carbon number distribution and thus more accurate than analysis techniques based on distillation characteristics, such as those determined in accordance with EN ISO 3405-2019. In other words, the carbon range gives a good impression of the quality of the feed in terms of homogeneity.
  • the renewable stabilized naphtha-range hydrocarbon feed has an interventile carbon number range (IVR) of 6.5 or less, preferably 5.0 or less, 4.5 or less, 4.0 or less or 3.8 or less.
  • the IVR is the calculated carbon number range determined from a linear interpolation of data (accumulated content vs. carbon number) obtained from PIONA carbon number analysis.
  • IDR, IQR, and c_50 are determined from a linear interpolation of data (accumulated content vs. carbon number) obtained from PIONA carbon number analysis.
  • the IVR is the carbon number range containing 90% of the mass (i.e. from 5 wt.-% to 95 wt.-%).
  • the IQR is the carbon number range containing 50% of mass from 25 wt.-% to 75 wt.-% and the IDR (interdecile range) is the carbon number range containing 80% of mass from 10 wt.-% to 90 wt.-%.
  • the IQR is the carbon number range containing 50% of mass from 25 wt.-% to 75 wt.-% and the IDR (interdecile range) is the carbon number range containing 80% of mass from 10 wt.-% to 90 wt.-%.
  • Linear interpolation means that a content range between two carbon numbers is assumed to be linear.
  • a sample containing 0%Cl (0% components having 1 carbon atom) 0%C2, 0%C3, 5%C4, 5%C5 and 8%C6 will have a c_2.5 value (i.e. fractional carbon number representing 2.5 wt.-% of the sample) of 3.5 (carbon number) even though C4 is the lowest carbon number which is actually present.
  • the c_5 value fractional carbon number representing 5 wt.-% sample
  • the c_10 value (10 wt.-%) is 5 (C5), since the accumulated amount of C1+C2+C3+C4-I-C5 is exactly 10 wt.-%.
  • the c_15 value (15 wt.-%) is between 5 and 6 (C5 is 10 wt.-%, C6 is 18 wt.-%). Linear interpolation is easily calculated such that e.g. the 15 wt.-% content carbon number (c_15 value) is calculated to be 5 ⁇ highest carbon number not yet contributing 15 wt.-% ⁇ +
  • the linear interpolation can be easily understood from the graphical illustration of FIG. 1.
  • the y-axis represents the accumulated content of compounds and carbon numbers are arranged on the x-axis ordered by their number.
  • the bars represent individual content of compounds with the respective carbon number.
  • the dots represent the accumulated content (cumulative mass fraction) for the respective carbon number and the line graph represents the linear interpolation (i.e. drawing a straight line between neighbouring dots).
  • the carbon number where the line graph crosses the 50% cumulative mass fraction (horizontal line) is the c_50 value, which is slightly above 16 in FIG. 1, as shown by the dotted line.
  • the IVR, IDR and IQR ranges are less sensitive to tail effects and thus provide more stable results than the carbon range.
  • the renewable stabilized naphtha-range hydrocarbon feed has an interdecile carbon number range (IDR) of 4.5 or less, preferably 4.0 or less, 3.5 or less, or 3.0 or less.
  • the renewable stabilized naphtha-range hydrocarbon feed has an interquartile carbon number range (IQR) of 2.5 or less, preferably 2.0 or less, 1.8 or less, or 1.5 or less.
  • the renewable stabilized naphtha-range hydrocarbon feed has a content of Cll and higher carbon number components of less than 5.0 wt.- %, preferably 4.5 wt.-% or less, 4.0 wt.-% or less, 3.5 wt.-% or less, 3.0 wt.-% or less, 2.5 wt.-% or less or 2.0 wt.-% or less.
  • the content of Cll and higher carbon number components may be 0.0 to 5.0 wt.- %, or 0.1 to 5.0 wt.-%
  • the renewable stabilized naphtha-range hydrocarbon feed has a T95 temperature of 220°C or less, preferably 200°C or less, 180°C or less, 160°C or less, or 140°C or less.
  • the renewable stabilized naphtha-range hydrocarbon feed has a T99 temperature of 220°C or less, preferably 200°C or less, 180°C or less, 160°C or less, or 140°C or less.
  • the renewable stabilized naphtha-range hydrocarbon feed has a final boiling point of 220°C or less, preferably 200°C or less, 180°C or less, or 160°C or less.
  • the renewable stabilized naphtha-range hydrocarbon feed has an initial boiling point of 20°C or more, preferably 20°C to 60°C, such as 30°C to 50°C or 30°C to 45°C.
  • the renewable stabilized naphtha-range hydrocarbon feed has a T5 temperature of 40°C or more, preferably 45°C or more, 50°C or more, 55°C or more, or 60°C or more.
  • the renewable stabilized naphtha-range hydrocarbon feed has low contents of light and very light components.
  • the difference between the T10 temperature and the T90 temperature (T90-T10) of the renewable stabilized naphtha-range hydrocarbon feed is less than 100°C, preferably less than 80°C, such as 20°C to 75°C, 30°C to 70°C, or 40°C to 70°C.
  • T10 and T90 value largely disregards outliers (tails) in the boiling distribution and is thus a stable and very reliable measure for describing the homogeneity of a composition.
  • the renewable stabilized naphtha-range hydrocarbon feed has been found to produce favourable product distribution while still making use of a considerable amount of the material, thus contributing to high overall yield improvement.
  • the renewable stabilized naphtha-range hydrocarbon feed has a total paraffins content of 90 wt.-% or more, preferably 92 wt.-% or more, 93 wt.-% or more, 94 wt.-% or more or 95 wt.-% or more.
  • the content of total paraffins in the renewable stabilized naphtha-range hydrocarbon feed of the present invention refers to the summed amount of n-paraffins and i-paraffins relative to the total weight of the renewable stabilized naphtha-range hydrocarbon feed.
  • the renewable stabilized naphtha-range hydrocarbon feed has a content ratio of i-paraffins to n-paraffins in the range of 1.7 or less, preferably 1.5 or less, such as 0.5 to 1.7, or 0.7 to 1.5.
  • i-paraffins to n-paraffins ratio within the above limits provides a particularly high yield of ethylene.
  • the ratio is defined on a weight basis, i.e. content by weight of i-paraffins divided by content by weight of n-paraffins.
  • the renewable stabilized naphtha-range hydrocarbon feed has a content ratio of i-paraffins to n-paraffins in the range of 2.0 or more, preferably 2.2 or more.
  • i-paraffins (iP) to n-paraffins (nP) ratio within the above limits provides a particularly high yield of propylene.
  • i-paraffins (iP) to n-paraffins (nP) ratio provides a particularly high yield of propylene.
  • An intermediate range within 1.7 to 2.0 may be employed as well, though being not preferred because it is not optimal for ethylene production and not optimal for propylene production.
  • such a high iP/nP ratio lowers viscosity and improves mixing characteristics and blendability, which is particularly (but not exclusively) beneficial when employing a co-feed in the cracking step.
  • the renewable stabilized naphtha-range hydrocarbon feed is obtainable by a method as disclosed for the above-described step (a) of providing the renewable stabilized naphtha-range hydrocarbon feed in the method of the present invention.
  • the renewable stabilized naphtha-range hydrocarbon feed is preferably obtainable by a method comprising hydrotreatment of an oxygenate bio-renewable feed and optionally isomerisation.
  • the method preferably comprises the isomerisation.
  • renewable stabilized naphtha-range hydrocarbon feed employed in the method is preferably the renewable stabilized naphtha- range hydrocarbon feed disclosed herein, i.e. having the characteristics mentioned herein.
  • the renewable stabilized naphtha-range hydrocarbon feed may be obtainable or obtained by a method comprising subjecting an oxygenate bio-renewable feed to hydrotreatment comprising at least hydrodeoxygenation to provide a hydrotreatment effluent, subjecting at least part of the hydrotreatment effluent to gas-liquid separation to provide a gaseous stream and a first liquid hydrocarbon stream, providing the first liquid hydrocarbon stream as a liquid hydrocarbon stream or subjecting at least part of the first liquid hydrocarbon stream to a further hydrotreatment comprising at least hydroisomerisation, followed by optional further gas-liquid separation, to provide at least a second liquid hydrocarbon stream as the liquid hydrocarbon stream, and feeding at least part of the liquid hydrocarbon stream to a first distillation column, preferably a first stabilisation column, to obtain a first overhead fraction and a stabilised heavy liquid hydrocarbon fraction, optionally using at least part of the stabilised heavy liquid hydrocarbon fraction in diesel fuel and/or recovering from at least part of the stabilised heavy liquid hydrocarbon fraction at least an aviation fuel range
  • the present invention further relates to a renewable thermal cracking effluent having a benzene content of 6.0 wt.-% or less, a total content of ethylene and propylene of 45.0 wt.-% or more and a carbon monoxide content of 0.25 wt.-% or less.
  • the benzene content may be 0.01 wt.-% to 6.0 wt.-%, such as 0.1 wt.-% to 4.0 wt.-%, 0.1 wt.-% to 3.6 wt.-%, 0.1 wt.-% to 3.4 wt.-%, 0.1 wt.-% to 3.2 wt.-%, 0.1 wt.-% to 3.0 wt.-%, 0.1 wt.-% to 2.8 wt.-%, 0.1 wt.-% to 2.6 wt.-%, 0.2 wt.-% to 2.4 wt.-%, 0.3 wt.-% to 2.2 wt.-%, or 0.5 wt.-% to 2.0 wt.-% or less.
  • the renewable thermal cracking effluent has a total content of ethylene and propylene of 45 wt.-% to 65 wt.-%, preferably 46.0 wt.-% to 65.0 wt.-%, 47.0 wt.-% to 65.0 wt.-%, 48.0 wt.-% to 65.0 wt.-%, 49.0 wt.- % to 65.0 wt.-%, 50.0 wt.-% to 65.0 wt.-%, 50.0 wt.-% to 60.0 wt.-%, or 50.0 wt.-% to 55.0 wt.-%.
  • the renewable thermal cracking effluent has a total content of ethylene and propylene and total C4 olefins of 45 wt.-% to 80 wt.-%, preferably 50 wt.-% to 75 wt.-%, 50 wt.-% to 70 wt.-%, 50 wt.-% to 65 wt.- %, or 55 wt.-% to 65 wt.-%.
  • the renewable thermal cracking effluent has a total content of C4 olefins of at least 5.0 wt.-%, such as 5.0 wt.-% to 20.0 wt.-%, preferably 8.0 wt.-% to 20.0 wt.-%, 10.0 wt.-% to 20.0 wt.-%, 12.0 wt.-% to 20.0 wt.-%, 12.6 wt.-% to 20.0 wt.-%, 13.0 wt.-% to 20.0 wt.-%, or 13.5 wt.-% to 20.0 wt.-%.
  • 5.0 wt.-% such as 5.0 wt.-% to 20.0 wt.-%, preferably 8.0 wt.-% to 20.0 wt.-%, 10.0 wt.-% to 20.0 wt.-%, 12.0 wt.-% to 20.0 wt.-%, 12.6
  • the total C4 olefins refer to 1-butene, 2-butene (including cis-2-butene and trans-2-butene), 1,3-butadiene, and isobutene.
  • the total content of ethylene and propylene and total C4 olefins may also be referred to as total content of valuable light olefins.
  • the renewable thermal cracking effluent is preferably the effluent of the thermal cracking furnace of step (b) of the method of the present invention.
  • step (b) of the method preferably provides an effluent of the thermal cracking furnace having the properties of the renewable thermal cracking effluent mentioned herein.
  • the renewable thermal cracking effluent has a carbon monoxide content of 0.23 wt.-% or less, preferably 0.21 wt.-% or less, 0.20 wt.-% or less, 0.19 wt.-% or less, 0.18 wt.-% or less, 0.17 wt.-% or less, 0.16 wt.-% or less, 0.15 wt.-% or less, 0.14 wt.-% or less, 0.13 wt.-% or less, 0.12 wt.- % or less, 0.11 wt.-% or less, 0.10 wt.-% or less, or 0.09 wt.-% or less.
  • the present invention provides means to achieve very low CO contents even without the need for CO removal.
  • the renewable thermal cracking effluent has a C4 monoolefin content of 6.0 wt.-% or more, preferably 6.5 wt.-% or more, 6.8 wt.-% or more, 7.0 wt.-% or more, 7.2 wt-% or more, or 7.4 wt.-% or more.
  • the upper limit may for example be 15.0 wt.-%, such as 13.0 wt.-%.
  • the renewable thermal cracking effluent may for example have a C4 monoolefin content in the range of 6.0 wt.-% to 15.0 wt.-%, such as 6.5 wt.- % to 13.0 wt.-%.
  • the renewable thermal cracking effluent has an isobutene content of at least 2.0 wt.-%, preferably at least 2.4 wt.-%, more preferably at least 3.0 wt.-%, even more preferably at least 3.2 wt.-%.
  • the upper limit may for example be 10.0 wt.-%, such as 9.0 wt.-% or 8.0 wt.-%.
  • the renewable thermal cracking effluent may for example have an isobutene content in the range of 2.0 wt.-% to 10.0 wt.-%, such as 2.5 wt.-% to 9.0 wt.-% or 3.0 wt.-% to 8.0 wt.-%.
  • isobutene is highly attractive molecule as it can be easily converted by reacting with methanol or ethanol to obtain methyl tert-butyl ether (MTBE) or ethyl tert-butyl ether (ETBE), respectively, and transported, whereafter the MTBE/ETBE can be reversed in a similar manner to isobutene and the corresponding alcohol.
  • MTBE and ETBE are also highly valuable gasoline components.
  • the derivatives of isobutene are more valuable than derivatives of linear C4 olefins, including butyl rubber, polyisobutene, methylmethacrylate, gasoline alkylate, just to name a few.
  • isobutene from other C4 olefins is relatively simple, for example by reacting methanol or ethanol with an isobutene containing C4 olefins fraction to obtain MTBE or ETBE, respectively, followed by separating the formed ethers from the remaining C4 olefins mixture.
  • the renewable thermal cracking effluent has a total content of n- C4 monoolefins of 3.0 wt.-% or more, preferably 3.5 wt.-% or more, such as 4.0 wt.-% or more.
  • the upper limit may for example be 15.0 wt.-%, such as 12.0 wt.-%, or 10.0 wt.-%.
  • the renewable thermal cracking effluent has a 1,3-butadiene content of at least 5.0 wt.-%, preferably at least 5.5 wt.-%, more preferably at least 6.0 wt.-%, or at least 6.2 wt.-%.
  • the upper limit may for example be 15.0 wt.-%, such as 13.0 wt.-% or 11.0 wt.-%.
  • the renewable thermal cracking effluent may for example have a 1,3 butadiene content in the range of 5.0 wt.-% to 15.0 wt.-%, such as 5.5 wt.-% to 13.0 wt.-% or 5.5 wt.-% to 11.0 wt.-%.
  • the renewable stabilized naphtha-range hydrocarbon feed of the present invention is particularly suitable for achieving high butadiene content.
  • this feed is similarly suitable as a fossil naphtha and thus may be co-feed with fossil naphtha in broad blending ratios without a drop in the butadiene content.
  • the renewable thermal cracking effluent has a toluene content in the range of from 0.2 wt.-% to 1.8 wt.-%, preferably 0.2 wt.-% to 1.6 wt.-
  • a thermal cracking effluent of the present invention is particularly suitable for further upgrading into monomer(s) for polymerisation.
  • feed compositions Cl, C2, C3, El and E2
  • a fossil feed composition (Cl) corresponds to a conventional fossil light naphtha.
  • the remaining four feeds correspond to hydrotreated and isomerised bio-renewable fat/oil having varying degrees of isomerisation and boiling point range.
  • feed composition C2 is a broad-cut naphtha composition
  • feed composition C3 is a highly isomerized diesel range composition
  • feed composition El is a stabilized naphtha range composition
  • feed composition E2 is a stabilized and highly isomerised naphtha range composition.
  • the five compositions were subjected to steam cracking at two distinct coil outlet temperatures (COT) of 820°C and 850°C at a dilution (water/oil ratio) of 0.5 and a coil outlet pressure (COP) of 1.7 bar (absolute).
  • COT coil outlet temperatures
  • COP coil outlet pressure
  • the steam cracker feed compositions El and E2 according to the present invention provide low aromatics and high light olefins yield, especially at relatively low COT.
  • low COT may be employed while still achieving high yield.
  • low coke formation was observed for the inventive compositions and for fossil naphtha composition Cl.
  • the cracking effluent produced from fossil naphtha shows high benzene content.
  • the low-to-moderately isomerized composition El particularly provides improved yield of ethylene and butadiene and the highly-isomerized composition E2 provides particularly good yield of propylene and C4 monoolefins.
  • the combined yield of ethylene and propylene may be further increased by separating and recycling formed C2- C4 paraffins.
  • the product slate can be easily adjusted to a desired direction depending e.g. on market demand, product price, further purification or post-processing capacity, etc: for example by selecting a renewable stabilized naphtha-range hydrocarbon feed having a lower content ratio of i-paraffins to n-paraffins and/or using a higher COT in the thermal cracking, it is possible to increase the weight ratios of ethylene to propylene and 1,3-butadiene to C4 monoolefins in the cracking effluent.

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  • Engineering & Computer Science (AREA)
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  • Organic Chemistry (AREA)
  • Physics & Mathematics (AREA)
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  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)

Abstract

La présente invention concerne un procédé comprenant un craquage thermique, une charge d'hydrocarbures de gamme naphta stabilisée renouvelable utilisable dans un tel procédé et un effluent de craquage pouvant être obtenu par l'utilisation d'un tel procédé. Le procédé de la présente invention comprend une étape (a) consistant à fournir une charge d'hydrocarbures de gamme naphta stabilisée renouvelable, une étape (b) consistant à craquer thermiquement la charge d'hydrocarbures de gamme naphta stabilisée renouvelable dans un four de craquage thermique, éventuellement conjointement avec une ou plusieurs co-charges et/ou un ou plusieurs additifs, et une étape (c) consistant à soumettre l'effluent du four de craquage thermique de l'étape (b) à un traitement de séparation pour fournir au moins une fraction d'oléfine(s) légère(s).
PCT/FI2022/050771 2021-12-27 2022-11-21 Charge d'hydrocarbures de gamme naphta stabilisée renouvelable, procédé de craquage thermique et produits associés Ceased WO2023126567A1 (fr)

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KR1020247020041A KR20240107331A (ko) 2021-12-27 2022-11-21 재생 가능한 안정화된 나프타 범위의 탄화수소 공급물, 열 분해 방법 및 이의 생성물
CA3237286A CA3237286A1 (fr) 2021-12-27 2022-11-21 Charge d'hydrocarbures de gamme naphta stabilisee renouvelable, procede de craquage thermique et produits associes
JP2024539335A JP2025501191A (ja) 2021-12-27 2022-11-21 再生可能な安定化ナフサ範囲炭化水素フィード、その熱分解方法およびその製品
EP22813634.7A EP4457312A1 (fr) 2021-12-27 2022-11-21 Charge d'hydrocarbures de gamme naphta stabilisée renouvelable, procédé de craquage thermique et produits associés
US18/724,301 US20250066682A1 (en) 2021-12-27 2022-11-21 Renewable stabilized naphtha-range hydrocarbon feed, thermal cracking method and products thereof
CN202280084059.6A CN118369403A (zh) 2021-12-27 2022-11-21 可再生的稳定石脑油范围烃进料、热裂化方法及其产品

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FI20216353A FI20216353A1 (en) 2021-12-27 2021-12-27 RENEWABLE STABILIZED NAFTA AREA HYDROCARBON FEED, THERMAL CRACKING METHOD AND ITS PRODUCTS

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KR20240107331A (ko) 2024-07-09
CA3237286A1 (fr) 2023-07-06
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